Hybrid PDMS Testing and Techno-economic Model Library/Events/2014/2014 NETL CO2... · Hybrid PDMS...
Transcript of Hybrid PDMS Testing and Techno-economic Model Library/Events/2014/2014 NETL CO2... · Hybrid PDMS...
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the ENERGY lab
Nicholas Siefert
Hybrid PDMS Testing and Techno-economic Model
Task Technical Coordinator Pre-combustion Solvents NETL CO2 Capture Conference
8/1/2014
Team Members: Sweta Agarwal, Hunaid Nulwala, Elliot Roth, Fan Shi, Wei Shi, David Miller, Dave Hopkinson, Bob Enick, John Kitchin, and Dave Luebke
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• Overall goal of project • Experimental Data on Pre-combustion Solvents • Discussion of Process Flow Diagram • Capital & Operating Cost Breakdown of Equipment • Economic Model / Levelized Cost Estimate • Future work
Outline
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• Objective: Lower the cost of capturing CO2 from syngas • Approach: Develop hydrophobic solvents for separation of
CO2 from warm syngas
High Molecular Weight PDMS - Background
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• Higher CO2 and H2S selectivity against H2 at lower temperature
• Constraint: Selexol will absorb any remaining water in syngas
Background: Why Selexol must operate < 40oC
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0%10%20%30%40%50%60%70%80%90%
100%
40 90 140 190Syngas Temperature [°C]
Water Remaining in Syngas vs. Temperature
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Experimental Results
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Selexol vs. Hybrid @25oC
• Hydrophilic • Viscosity = 5.8 cP • MW = 280 • Specific heat = 2.06 kJ/kg∙K • Density = 1030 kg/m3
• Thermal cond = 0.19 W/m∙K • Surface tension ~ 32 mN/m • Vapor Pressure = 0.0007
mmHg • CO2/H2 selectivity ~ 80
• Hydrophobic • Viscosity = 4.8 cP • MW = 438 • Specific heat = 1.77 kJ/kg∙K • Density ~ 936 kg/m3
• Thermal cond = TBD* • Surface tension = 22.1 mN/m • Vapor Pressure << 0.0007
mmHg • CO2/H2 selectivity ~ 40
Selexol *AspenPlus estimates that the thermal conductivity is 0.10 W/m∙K
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CO2 Solubility in Hybrid-PDMS 25°C
Experimental NETL
Experimental U. Pitt
Experimental NCCC
ComputationalSimulation NETL
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• 8 L of Hybrid PDMS-PEGDME were synthesized at NETL and shipped to NCCC
• Hybrid solvent was tested for CO2 solubility at 20oC and 40oC
• Solvent had tendency to foam and create fine aerosols at higher temperatures – Due to low surface tension,
low viscosity, and low density – Increases absorber diameter,
but can decrease height
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PDMS Scale up & NCCC Testing
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Selexol vs. Ionic Liquid @25oC
• Hydrophilic • Viscosity = 5.8 cP • MW = 280 • Specific heat = 2.06 kJ/kg∙K • Density = 1030 kg/m3
• Thermal cond = 0.19 W/m∙K • Surface tension ~ 32 mN/m • Vapor Pressure = 0.0007
mmHg • CO2/H2 selectivity ~ 80
• Hydrophobic (0.23 wt% H2O) • Viscosity = 28 cP (wet) • MW = 399 • Specific heat = 1.11 kJ/kg∙K • Density ~ 1515 kg/m3
• Thermal cond = TBD* • Surface tension = TBD* • Vapor Pressure <<< 0.0007
mmHg • CO2/H2 selectivity ~ 150
Selexol
Ionic Liquid Selexol
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CO2 Solubility at 25oC in different Solvents
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System Modeling
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System Modeling: Data Regression in Aspen Plus
• Data Regression to estimate the required pure and binary parameters
• Regression requires input of both thermodynamic & kinetic variable
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• PC-SAFT method used for H-PDMS and Selexol
• ENRTL-RK method used for Ionic Liquid
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System Modeling: Aspen Plus Modeling
• Model for Physical Solvent based CO2 capture using flash regeneration adapted from MIT IGCC-Selexol capture Aspen Model
15 Field and Brasington, “Baseline Flowsheet Model for IGCC with Carbon Capture,” Ind. Eng. Chem. Res., 2011, 50 (19), p 11306.
Rate-based Absorber
HP Flash-Recycle
Pressure Swing Regeneration
Solvent Chiller
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System Modeling: Aspen Plus Modeling
• Base Model for CO2 capture using flash regeneration adapted from MIT IGCC-Selexol capture Aspen Model
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Field and Brasington, “Baseline Flowsheet Model for IGCC with Carbon Capture,” Ind. Eng. Chem. Res., 2011, 50 (19), p 11306.
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Our Economic Model
• Economic Model Assumptions: – There is an existing IGCC Power Plant with H2S Removal – 1 Years for Construction (for CO2 Capture Equipment) – 30 Years of Operations with O&M = 4% of Capital per year – 80% Capacity Factor – 5% Inflation-Adjusted Interest Rate – Plant Cost Ratio = 5 = Total Capital Cost / Bare Equipment Costs – Bare Capital Cost estimates calculated from equations taken
from various sources (Sieder Textbook, AspenPlus, IECM) • Used to calculate the levelized cost of capturing CO2
– Levelized cost = Operating costs plus capital costs levelized per ton of CO2 captured
– Values are normalized compared with Selexol
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Operating Cost Incurred due to lower power
genreation 34.7%
Operating Cost Incurred due to lost H2
1.3% CO2 Compression
Operating Cost 19.5%
Solvent Based CO2 Capture
Operating Cost 10%
Fixed O&M 13.8%
CO2 Compression Capital Cost
9.7%
Solvent based CO2 Capture Capital Cost
10%
WGS Capital Cost 1.8%
Operating & Levelized Capital Cost Distribution Chart: Selexol Normalized
Value = 1.00 For Levelized Cost per CO2 Captured
Note: Levelized Cost at 10°C was less than 40°C
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Comparison of Levelized Cost of Capture
Fixed O&M Cost
Levelized WGS, Captureand Compression CapitalCost
Capture Operating Cost
Compression OperatingCost
Gas not going to BraytonCycle Penalty Cost
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Future Work
• Test Ionic Liquid Solvent at NCCC, and continue testing at NETL
• H2S testing for both H-PDMS and Ionic Liquid
• Model both H-PDMS and Ionic Liquid in a full IGCC-CCS system model with two-stage H2S/CO2 removal
• Include H2 & H2O separating membrane upstream of two-stage H2S/CO2 removal in order to potentially lower the levelized cost even further
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• Thanks to: NETL SCC, Sweta Agarwal, Hunaid Nulwala, Elliot Roth, Fan Shi, Wei Shi, Regina Woloshun, David Miller, Dave Hopkinson, Bob Enick, John Kitchin, and Dave Luebke
Thank You
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Back-up Slides
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Glossary
PC-SAFT : Perturbed Chain statistical associating fluid theory NRTL: Non-random two-liquid ENRTL-RK: Electrolyte NRTL with Redlich Kwong vapor phase properties
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System Modeling: Preliminary Results of Net Power Consumed
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Enick et al., “Hydrophobic polymeric solvents for the selective absorption of CO2 from Warm Gas Stream that also contain H2 and H2O,” CCUS Conference, Pittsburgh, PA, May 15 2013
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Enick et al., “Hydrophobic polymeric solvents for the selective absorption of CO2 from Warm Gas Stream that also contain H2 and H2O,” CCUS Conference, Pittsburgh, PA, May 15 2013
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PDMS Solubility using Raman: Dr. Kitchin CMU
CO2
H2 • CO2 and H2 Raman
spectroscopy can be used to determine solubility
CO2 and H2 Raman spectroscopy can be used to determine selectivity
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Absorber: $11M
Flash Units & Separator: $1.5M
Bare Equipment Costs: H-PDMS
Recycle Compressor and Cooler : $2M
Solvent Pump: $0.5M
Solvent Chiller: $4M
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Bare Equipment Costs: CO2 Compression Cycle
150 atm liquid CO2 21 atm 80 atm
11 atm
Cost of LP Compressor and Intercooler: $4.5M
Cost of MP, HP Compressors, Intercoolers and Liquid CO2 Pump: $12.7M
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Operating Cost Incurred due to lower power
genreation 35.4%
Operating Cost Incurred due to lost H2
1.4%
CO2 Compression Operating Cost
18.8%
Solvent Based CO2 Capture
Operating Cost 10%
Fixed O&M 13.6%
CO2 Compression Capital Cost
9.0%
Solvent based CO2 Capture Capital Cost
10%
WGS Capital Cost 1.9%
Levelized Cost Distribution Chart: H-PDMS
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Operating Cost Incurred due to lower power
genreation 35.4%
Operating Cost Incurred due to lost H2
1.4%
CO2 Compression Operating Cost
18.8%
Solvent Based CO2 Capture
Operating Cost 10%
Fixed O&M 13.6%
CO2 Compression Capital Cost
9.0%
Solvent based CO2 Capture Capital Cost
10%
WGS Capital Cost 1.9%
Levelized Cost Distribution Chart: H-PDMS Normalized to
Selexol, Levelized Cost per CO2 Captured = 0.98 +/-0.07 Uncertainty reflects uncertainty in CO2&H2 Solubility as measured by different researchers
Note: Levelized Cost at 10°C was less than 40°C
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Operating Cost Incurred due to lower power
genreation 43.1%
Operating Cost Incurred due to lost H2
0.2%
CO2 Compression Operating Cost
22.5%
Solvent Based CO2 Capture
Operating Cost 10%
Fixed O&M 11.3%
CO2 Compression Capital Cost
10.9%
Solvent based CO2 Capture Capital Cost
10%
WGS Capital Cost 2.3%
Levelized Cost Distribution Chart: NETL Ionic Liquid Normalized to
Selexol, Levelized Cost per CO2 Captured = 0.79 +/-0.04 Uncertainty reflects uncertainty in H2 Solubility
Note: Levelized Cost at 40°C was less than 10°C